Determination of gas pressure and saturation simultaneously

ABSTRACT

A pulsed neutron tool with three or more detectors is used for making measurements inside casing. The measurements may be used to determine gas saturation at a constant gas pressure, pressure at constant gas saturation, or to determine both gas saturation and gas pressure.

CROSS-REFERENCES TO RELATED APPLICATIONS

This application is related to U.S. patent application Ser. No.11/189,388 and U.S. patent application Ser. No. 11/189,455 having thesame inventors being filed concurrently with the present application.

BACKGROUND OF THE INVENTION

This invention relates generally to oil and gas well logging tools. Moreparticularly, this invention relates tools for measuring gas saturationand gas pressure of earth formations through the use of gamma raysgenerated by a pulsed neutron source. This invention may be used incased holes as well as open holes.

In petroleum and hydrocarbon production, there is considerablecommercial value in the recovery of gas from reservoirs. Over the courseof production of gas, there is an increasing influx of water into thereservoir. This may be due to natural causes or it may be, in the caseof secondary recovery operations, the result of injection of water intothe reservoir. The production of gas thus leads to a decrease in gassaturation of the reservoir. In addition, due to the fact thatreservoirs by their very nature comprise permeable earth formationswithin impermeable strata, production of gas leads to a decrease of gaspressure. The decrease of gas pressure in turn affects the flow patternof reservoir fluids. Knowledge of the gas pressure is also very helpfulin reservoir development. Knowledge of gas saturation is also importantin enhanced oil recovery programs (EOR) where a gas is injected into aninjection well and used to direct the flow of oil from the reservoirinto a production well.

A basic methodology underlying the determination of gas saturationand/or gas pressure is that of density determination. One approachinvolves detection of gamma radiation produced in the formation inresponse to a high-energy neutron source, referred to as induced gammaray logging. When the neutron source is pulsed, gamma rays are producedby one of two reactions. The first is inelastic scattering of fastneutrons (neutrons with energies above about one MeV or within about oneorder of magnitude). The second mechanism is from capture of epithermalneutrons (neutrons with energy of about one eV). The third is fromcapture of thermal neutrons (neutrons with energy of about 0.025 eV).The fast-neutron lifetimes are very small (a few microseconds) such thatduring the source pulse a mixed-energy neutron field exists. Shortlyafter the burst, all neutrons slow down to a thermal energy level andthese thermal neutrons wander about until being captured, with alifetime in the hundreds of microseconds. Gamma rays from inelasticscattering are produced in close proximity to the accelerator, and gammarays from thermal capture are dispersed farther from the accelerator (upto tens of centimeters). The number of capture gamma rays is stronglyinfluenced by the amount of hydrogen and the thermal neutron capturecross section of the formation. The number of gamma rays produced frominelastic scattering is less dependent on these quantities, and ameasurement of such gamma rays is more directly related to the formationdensity. Use of a pulsed neutron source allows capture gamma rays to beseparated from inelastic gamma rays, giving a better estimate ofdensity.

U.S. Pat. No. 3,780,301 to Smith Jr. et al. discloses a method andapparatus for determination of gas saturation using a logging tooldeployed in an open borehole. A pulsed neutron source produces pulses ofneutrons with energy of about 14 MeV. A single gamma ray detectormeasures counts of inelastic gamma rays resulting from interaction ofthe neutrons with nuclei in the formation. Specifically, counts are madein energy bands corresponding to C, O, Si and Ca. By comparing the Si/Caand C/O ratios in these regions to the Si/Ca and C/O ratios for a knownwater sand, the relative abundance of limestone in the low hydrogencontent formations may be estimated thus distinguishing gas zones fromwater saturated low porosity limestone.

When the wellbore in which the tool is run is an uncased reservoir, thetool is able to contact the subterranean formation itself. However, oncea well has been cased, there exists a layer of steel and concretebetween the interior of the wellbore where the tool is located and theformation itself. The well casing makes it difficult for signals to passbetween the tool and the reservoir and visa versa. In addition, thecement can confuse the measurement of formation properties.

Formation density measurements have traditionally been made using twogamma ray detectors. In open hole situations, density estimates ρ_(SS)and ρ_(LS) made by the near and far detectors are used to get acorrected density estimate using the spine and rib method which may berepresented by the equationρ−ρ_(LS)=Δρ=ƒ(ρ_(LS)−ρ_(SS))  (1),where ƒ(.) is a function that is nonlinear, depends upon the standoff ofthe tool or the amount of mud cake between the tool and formation, anddetermined by a calibration process. This dual detector arrangement isable to compensate for standoff (in MWD applications) and mudcakethickness (in wireline applications). When used with a pulsed neutronsource, correction also has to be made for variations in the sourceintensity, so that a two detector arrangement only gives a singleestimate of density based on, for example, a ratio of the outputs of thetwo detectors.

For measurements made in cased holes, as noted above, there is anadditional complication due to the presence of casing and cement. Inorder to probe the formation, neutrons must exit the tool, pass throughthe casing and cement and scatter, or be captured in the formationbefore the resulting gamma rays pass passing back through the cement andthe casing to finally reenter the tool to be detected. Thus, instead ofjust a mudcake correction (for open hole wireline) or a standoffcorrection (for MWD), a cased hole density tool must be able to corrector compensate for the cement and casing, an effect which is greater thanthat of the mudcake. U.S. Pat. No. 5,525,797 to Moake discloses the useof a three detector tool using a chemical gamma ray source whichcorrects for the effects of casing. A drawback of the Moake device isthe need for a relatively high energy chemical source (a safety issue)and the fact that gamma ray energies are measured (instead of countrates). In addition, it is not possible to separate inelastic gamma raysfrom capture gamma rays.

U.S. Pat. No. 5,825,024 to Badruzzaman discloses an apparatus formeasuring the density of a subterranean formation from within awellbore, especially a cased wellbore. The apparatus has an energysource configured to generate 14 MeV of neutrons in pulses of 20microseconds or less. The apparatus has at least three detectors fordetecting gamma rays which are produced as a result of the neutronpulse. The detectors and energy source are aligned along a central axiswith the energy source being at one end. Shielding is disposed betweeneach of the three detectors and between the end detector and the energysource adjacent to it. The detectors are configured to measure gammarays below 700 KeV and generate a signal in response thereto. Thesignals may then be compared to predetermined characteristic signals orcomputer simulations to determine the density, and hence porosity, ofthe formation.

Badruzzaman et al. (SPE89884) discuss the use of a four sensorarrangement for through-casing density measurements with a pulsedneutron source. These included a pseudo-density determination, C/Omeasurements for oil saturation determination, and pulsed neutroncapture (PNC) cross section measurements for water and steam saturation.

None of the prior art recognizes the inter-relation between the effectsof gas saturation and gas pressure on the measurements made by a nuclearlogging tool. The present invention recognizes the inter-relation andrepresents a comprehensive approach to the determination of reservoircharacteristics through casing.

SUMMARY OF THE INVENTION

One embodiment of the invention is a method of evaluating an earthformation having a gas therein. The earth formation is irradiated with asource of neutrons in a borehole. Radiation resulting from interactionof the neutrons with nuclei in the earth formation is measured at atleast one detector spaced apart from the source. From the measurements,a value of a gas saturation S_(g) and a gas pressure P_(g) is estimated.Estimating S_(g) and P_(g) may further involve determining from a firstsubset of the measurements a value of a gas zone parameter (GZP)indicative of S_(g) and P_(g) at at least one depth in the borehole,determining from a second subset of the measurements a value of aCarbon/Oxygen (C/O) ratio, and estimating from the determined value ofthe GZP and the C/O ratio the values of S_(g) and P_(g). The boreholemay be a cased borehole. A pulsed neutron source may be used. Theinteraction may involve inelastic scattering. Two or more detectors maybe used with the GZP being related to a ratio of measurements made bytwo detectors. Determining the values of the GZP may be based on aformation mineralogy, a formation porosity, a tool responsecharacteristic, a formation fluid density, a borehole fluid density, aborehole diameter, a casing diameter, a gas density, and/or an equationof state. A Monte Carlo simulation may be used. Estimating the values ofS_(g) and P_(g) may be based on determining a value of S_(g) and a gasdensity ρ_(g) that correspond to the determined value of GPZ and thedetermined value of the C/O ratio. Estimating the values of S_(g) andP_(g) may be based on using an equation of state.

Another embodiment of the invention is an apparatus for evaluating anearth formation having a gas therein, the apparatus includes a source ofneutrons conveyed in a borehole in the earth formation. The sourceirradiates the earth formation. At least one detector spaced apart fromthe source produces signals indicative of results of interaction of theradiation with nuclei in the earth. A processor which estimates from thesignals a value of a gas saturation S_(g) and a gas pressure P_(g). Theprocessor may estimate the value of S_(g) and P_(g) by furtherdetermining from a first subset of the signals a value of a gas zoneparameter (GZP) indicative of a gas saturation S_(g) and a gas pressureP_(g) at at least one depth in the borehole, determining from a secondsubset of the signals a value of a carbon/oxygen (C/O) ratio, and usingthe determined value of the GZP and the determined value of the C/Oratio. The borehole may be a cased borehole. The neutron source may be apulsed source. The interaction may be inelastic scattering. Two or moredetectors may be used with the GZP being related to a ratio ofmeasurements made by one of the two detectors to measurements made byanother of the two detectors. The processor may establish the values ofthe GZP using a formation mineralogy, a formation porosity, a toolresponse characteristic, a formation fluid density, a borehole fluiddensity, a borehole diameter, a casing diameter, a gas density, and/oran equation of state. A Monte Carlo simulation may be used. Theprocessor may estimate the values of S_(g) and P_(g) by furtherdetermining a value of S_(g) and a gas density ρ_(g) that correspond tothe determined value of GPZ and the determined value of the C/O ratio.The processor may estimate the values of S_(g) and P_(g) by furtherusing an equation of state. The apparatus may include a wireline or aslickline which convey the source of neutrons into the borehole

Another embodiment of the invention is a machine readable medium for usewith an apparatus for evaluating an earth formation having a gastherein. The apparatus includes a source of neutrons conveyed in aborehole in the earth formation, the source irradiating the earthformation, and at least one detector spaced apart from the source, theat least one detector producing signals indicative of results ofinteraction of the radiation with nuclei in the earth formation. Themedium includes instructions which enable a processor to determine fromthe signals a value of a gas zone parameter (GZP) indicative of a gassaturation S_(g) and a gas pressure P_(g) at at least one depth in theborehole, to determine from the signals a value of carbon/oxygen (C/O)ratio, and to estimate from the determined value of the GZP and thedetermined value of the C/O ratio a value of S_(g) and a value of P_(g).The medium may be a ROM, an EPROM, an EEPROM, a Flash Memory, and/or anoptical disk.

BRIEF DESCRIPTION OF THE FIGURES

The present invention is best understood with reference to theaccompanying figures in which like numerals refer to like elements andin which:

FIG. 1 (prior art) is an overall schematic diagram of the nuclear welllogging system of the present invention;

FIG. 2 (prior art) illustrates the generation of gamma rays by inelasticscattering and capture of thermal and epithermal neutrons;

FIG. 3 is a flow chart illustrating one part of the invention relatingto determination of gas saturation and gas pressure;

FIG. 4 shows an exemplary variation of the Gas Zone Parameter (GZP) as afunction of porosity for a water and a gas saturated reservoir;

FIG. 5 is an exemplary display of the GZP in a well used in enhanced oilrecovery;

FIG. 6 shows an example of the effect of gas pressure on the variationof the Gas Zone Parameter (GZP) as a function of effective porosity fora water and a gas saturated reservoir;

FIG. 7 shows an example of a gas reservoir having a depleted zone;

FIG. 8 illustrates the principle of using GZP and C/O measurements todetermine saturation and pressure;

FIG. 9 is an exemplary plot showing variation of the C/O ratio as afunction of effective porosity for different formation fluids; and

FIG. 10 is a flow chart illustrating the methodology for simultaneousdetermination of formation pressure and gas saturation from GZP and C/Oratios.

DETAILED DESCRIPTION OF THE INVENTION

The system shown in FIG. 1 is a prior art system for density logging.Well 10 penetrates the earth's surface and may or may not be caseddepending upon the particular well being investigated. Disposed withinwell 10 is subsurface well logging instrument 12. The system diagramedin FIG. 1 is a microprocessor-based nuclear well logging system usingmulti-channel scale analysis for determining the timing distributions ofthe detected gamma rays. Well logging instrument 12 includes anextra-long spaced (XLS) detector 17, a long-spaced (LS) detector 14, ashort-spaced (SS) detector 16 and pulsed neutron source 18. In oneembodiment of the invention, XLS, LS and SS detectors 17, 14 and 16 arecomprised of suitable material such as bismuth-germanate (BGO) crystalsor sodium iodide (NaI) coupled to photomultiplier tubes. To protect thedetector systems from the high temperatures encountered in boreholes,the detector system may be mounted in a Dewar-type flask. Thisparticular source and flask arrangement is an example only, and shouldnot be considered a limitation. Also, in one embodiment of theinvention, source 18 comprises a pulsed neutron source using a D-Treaction wherein deuterium ions are accelerated into a tritium target,thereby generating neutrons having energy of approximately 14 MeV. Thisparticular type of source is for exemplary purposes only and not to beconstrued as a limitation. The filament current and accelerator voltageare supplied to source 18 through power supply 15. Cable 20 suspendsinstrument 12 in well 10 and contains the required conductors forelectrically connecting instrument 12 with the surface apparatus.

The outputs from XLX, LS and SS detectors 17, 144 and 16 are coupled todetector board 22, which amplifies these outputs and compares them to anadjustable discriminator level for passage to channel generator 26.Channel generator 26 is a component of multi-channel scale (MCS) section24 which further includes spectrum accumulator 28 and central processorunit (CPU) 30. MCS section 24 accumulates spectral data in spectrumaccumulator 28 by using a channel number generated by channel generator26 and associated with a pulse as an address for a memory location.After all of the channels have had their data accumulated, CPU 30 readsthe spectrum, or collection of data from all of the channels, and sendsthe data to modem 32 which is coupled to cable 20 for transmission ofthe data over a communication link to the surface apparatus. Channelgenerator 26 also generates synchronization signals which control thepulse frequency of source 18, and further functions of CPU 30 incommunicating control commands which define certain operationalparameters of instrument 12 including the discriminator levels ofdetector board 22, and the filament current and accelerator voltagesupplied to source 18 by power supply 15.

The surface apparatus includes master controller 34 coupled to cable 20for recovery of data from instrument 12 and for transmitting commandsignals to instrument 12. There is also associated with the surfaceapparatus depth controller 36 which provides signals to mastercontroller 34 indicating the movement of instrument 12 within well 10.The system operator accesses the master controller 34 to allow thesystem operator to provide selected input for the logging operation tobe performed by the system. Display unit 40 and mass storage unit 44 arealso coupled to master controller 34. The primary purpose of displayunit 40 is to provide visual indications of the generated logging dataas well as systems operations data. Storage unit 44 is provided forstoring logging data generated by the system as well as for retrieval ofstored data and system operation programs. A satellite link may beprovided to send data and or receive instructions from a remotelocation.

In a well logging operation such as is illustrated by FIG. 1, mastercontroller 34 initially transmits system operation programs and commandsignals to be implemented by CPU 30, such programs and signals beingrelated to the particular well logging operation. Instrument 12 is thencaused to traverse well 10 in a conventional manner, with source 18being pulsed in response to synchronization signals from channelgenerator 26. Typically, source 18 is pulsed at a rate of 1000bursts/second (1 KHz). This, in turn, causes a burst of high energyneutrons on the order of 14 MeV to be introduced into the surroundingformation to be investigated. As discussed below with reference to FIG.2, this population of high energy neutrons introduced into the formationwill cause the generation of gamma rays within the formation which atvarious times will impinge on XLS, LS and SS detectors 17, 14 and 16. Aseach gamma ray thus impinges upon the crystal-photomultiplier tubearrangement of the detectors, a voltage pulse having an amplituderelated to the energy of the particular gamma ray is delivered todetector board 22. It will be recalled that detector board 22 amplifieseach pulse and compares them to an adjustable discriminator level,typically set at a value corresponding to approximately 100 KeV. If suchpulse has an amplitude corresponding to an energy of at leastapproximately 100 KeV, the voltage pulse is transformed into a digitalsignal and passed to channel generator 26 of MCS section 24.

In addition, as would be known to those versed in the art, many of thefunctions of the components described with reference to FIG. 1 may becarried out by a processor. It should also be noted that the systemdescribed in FIG. 1 involves conveyance of the logging device into thewell by a wireline. However, it is envisaged that the logging devicecould be part of a measurement while drilling (MWD) bottom hole assemblyconveyed into the borehole by a drilling tubular such as a drillstringor coiled tubing. In addition, it should be noted that FIG. 1illustrates a tool in an open hole. The method and apparatus are equallywell suited for use in cased holes.

FIG. 2 shows an illustration of the logging tool suitable for use withthe present invention. The apparatus illustrated is that of theReservoir Performance Monitor (RPM) of Baker Atlas, Incorporated. Ameasurement device 100 comprises a neutron source 101 and three axiallyspaced apart detectors described below. The number of detectors shown inthe embodiment of FIG. 2 is only an example of the number of detectorsemployed in an embodiment of the present invention. It is not alimitation on the scope of the present invention. The measurement deviceof the present invention may comprise two or more detectors. The neutronsource 101 may be pulsed at different frequencies and modes fordifferent types of measurements. The short-spaced (SS) detector 105 isclosest to the source 101 The long-spaced (LS) detector is denoted by106, and the furthest detector 107 is referred to as the extra-largespaced (XLS) detector. Fast neutrons (approximately 14 MeV) are emittedfrom the source 101 and enter the borehole and formation, where theyundergo several types of interactions. During the first few microseconds(μs), before they lose much energy, some neutrons are involved ininelastic scattering with nuclei in the borehole and formation andproduce gamma rays. These inelastic gamma rays 120, have energies thatare characteristic of the atomic nuclei that produced them. The atomicnuclei found in this environment include, for example, carbon, oxygen,silicon, calcium, and some others.

Two or more gamma-ray detectors are employed, in one or more modes ofoperation. Such modes include, but are not limited to, a pulsed neutroncapture mode, a pulsed neutron spectrometry mode, a pulsed neutronholdup imager mode, and a neutron activation mode. In a pulsed neutroncapture mode, for example, the tool pulses at 1 kHz, and records acomplete time spectrum for each detector. An energy spectrum is alsorecorded for maintaining energy discrimination levels. Time spectra fromshort-spaced and long-spaced detectors can be processed individually toprovide traditional thermal neutron capture cross section information,or the two spectra can be used together to automatically correct forborehole and diffusion effects and produce results substantiallyapproximating intrinsic formation values.

In a pulsed neutron spectrometry mode, the instrument pulses at 10 kHz,for example, and records full inelastic and capture gamma ray energyspectra from each detector. These data are processed to determineelemental ratios including carbon/oxygen and calcium/silicon from theinelastic spectra and silicon/calcium from the capture spectra.

With the neutron generator turned off, the measurement apparatus canalso be used to detect the distribution of materials, tagged withradioactive tracers, that are injected into the well during welltreatments. In this manner, the effectiveness of operations such ashydraulic fracturing or gravel pack placement can be evaluated.

In an embodiment of the present invention, a pulsed neutron generatorwith improved reliability and higher output is coupled with high-speeddownhole microprocessor-controlled drivers and detector electronics. Thesystem supports multiple frequency operation and different detectiongate timings to make the different measurements. The modes of operationcan be selected from the surface with no need to pull the tool out ofthe well.

After just a few μs, most of the neutrons are slowed by either inelasticor elastic scattering until they reach thermal energies, about 0.025 eV.This process is illustrated schematically in FIG. 2 as the sequence ofsolid arrows 110. At thermal energies, neutrons continue to undergoelastic collisions, but they no longer lose energy on average. A few μsafter the neutron generator shuts off, the process of thermalization iscomplete. Over the next several hundred μs, thermal neutrons arecaptured by nuclei of various elements—again producing gamma rays, knownas capture gamma rays 130. A capture gamma ray energy spectrum yieldsinformation about the relative abundances of these elements. Theinelastic gamma rays are depicted by 120.

We next give a broad overview of the method of the present invention. Asnoted above, the objective is to determine gas saturation and/or gaspressure in a reservoir. We discuss first the situation in which the gaspressure is known and the objective is to determine the gas saturation.We next discuss the situation in which the gas saturation is known andthe objective is to determine the gas pressure. We finally discuss amethod of determining simultaneously the gas saturation and the gaspressure.

Turning now to FIG. 3, the methodology for determining gas saturation isdiscussed. The method is discussed in the context of processing of thedata subsequent to measurement and recording, but it is to be understoodthat some or all parts of the method can be implemented substantially inreal time. An initial depth is selected 151. Corresponding to theinitial depth, inelastic gamma ray measurements are made by the three ormore detectors 155. The depth information is used to identify 153parameters such as the mineralogy and effective porosity of the earthformation at the depth 151. The mineralogy and effective porosity may beobtained from prior measurements made under open-hole conditions, fromrock cuttings, from core samples etc. The effective porosity φ_(e) isgenerally less than the total porosity φ that is determined by porositylogging tools. Effective porosity is the proportion of void space thatexcludes sealed-off pores. It thus measures the pore volume that iseffectively interconnected. It may be determined, for example, by NMRmeasurements.

From the measurements made by the detectors 155, the ratio R_(IN13) ofthe near to the extra-long spacing detector for inelastic collisions isdetermined. This ratio has been found to be the most sensitive to theeffects of gas. It should be noted that the ratio R_(IN23) is alsosensitive to the formation gas, but the statistical variability of thisratio is generally greater than that of R_(IN12) and R_(IN13). In oneembodiment of the present invention, a weighted combination of themeasurements may be used. This weighted combination is discussed in U.S.patent application Ser. No. 10/955,867 of Gilchrist et al., now U.S.Pat. No. 7,235,402, having the same assignee as the present inventionand the contents of which are incorporated herein by reference. Wedefine any of these quantities as a Gas Zone parameter (GZP). It shouldalso be noted that the ratio R_(ATO13) of the capture gamma ray countsis even more sensitive to the presence of gas and may be used in oneembodiment of the invention. However, capture gamma ray counts are alsosensitive to factors such as formation salinity and shale minerals andproper correction is needed for these other factors. It should be notedthat during the time interval in which inelastic gamma rays aremeasured, there is also a contribution from capture gamma rays.Typically, both the inelastic and the capture gamma rays are measuredover the same energy band of approximately 0.1 MeV to 8 MeV. In oneembodiment of the invention, improved counts of inelastic gamma rays areobtained by correcting for the contribution from the capture gamma rays.A method of making this conection is disclosed, for example, in U.S.Pat. No. 5,374,823 to Odom. Other methods would be known to thoseskilled in the art.

A table look-up is performed 157 for bounds on the GZP. The table isgenerated using a Monte Carlo simulation. It should be noted that theterm “table look-up” as used herein is intended to include equationsderived from Monte Carlo simulation relating the various factorsconsidered in the simulation. The Monte Carlo simulation may includesuch factors as the formation mineralogy and effective porosity, theknown tool response characteristics, the formation fluid density, theborehole fluid density, the borehole diameter and the casing diameter.In one embodiment of the invention, four broad minerals are considered:sandstones, shales, limestone and dolomite. In one embodiment of theinvention, the gas pressure is taken as a known quantity and the tablelook-up is for a fixed gas pressure. The gas pressure may be determinedusing flow tests. The density of the formation fluid may be determinedusing devices such as that disclosed in U.S. Pat. No. 5,473,939 toMichaels et al., having the same assignee as the present invention andthe contents of which are incorporated herein by reference. Densitymeasurements may also be made at the surface. The borehole fluidproperties may be measured at the surface and appropriate temperatureand pressure corrections applied for downhole conditions.

Based on the table look-up, a value is generated for 0% gas saturationand 100% gas saturation. These are the bounds (referred to as theenvelope) for the GZP 159. Values for the bounds and the GZP are storedfor display 161 and the next depth is processed 163. This processcontinues until all the depths have been processed. It should be notedthat curves may also be generated for additional values of S_(g). Therelationship between GZP and S_(g) at constant gas pressure is notlinear, so that for quantitative analysis, nonlinear or linearinterpolation or extrapolation may be done.

FIG. 4 illustrates the qualitative foundation for the gas envelope. Theabscissa represents the effective porosity of a gas sand within thereservoir while the ordinate is the GZP. The curve 221 is the GZP forS_(g)=0 while the curve 223 is the GZP for S_(g)=1 for a given gasdensity (which corresponds to a fixed gas pressure). As the gas sweep ofthe reservoir progresses, the gas saturation progressively increases,denoted by the arrow 227, and can be readily seen in a display such asthat in FIG. 5 during the course of EOR operations.

FIG. 5 shows an exemplary display generated by the present invention.The data are from a well in a limestone reservoir that is part of anenhanced oil recovery program The curve 241 corresponds to the “wet”side, i.e., 0% gas saturation. The curve 245 corresponds to 100% gassaturation and represents the “gas” side. The curve 243 is the measuredvalue of the GZP. It can be seen that in the zone identified as 247, thecurve 243 departs from the wet side curve 241: this is an indication ofthe presence of gas, the degree of separation being indicative of thegas saturation. It should be noted that the relationship is notnecessarily linear, so that linear or nonlinear interpolation orextrapolation may be used to quantify the gas saturation. In the zoneidentified as 249, the curve 243 basically overlies the wet curve 241and is an indication of a wet zone with an absence of gas.

While the example given above is for an EOR operation, similar resultsmay be obtained in gas wells: the separation of the GZP from the “wet”value may be used for identifying gas sands within the reservoir.Subsequent development of the reservoir would then be based onperforating the casing at the identified gas intervals and producing thegas.

In another embodiment of the invention, the gas pressure may bedetermined. The basis for this is illustrated in FIG. 6. This is similarin appearance to FIG. 4. Here, the curve 223 represents the GZP as afunction of effective porosity and may correspond to the initial gaspressure of a gas reservoir. As production continues, and assuming thatthere is no influx of water in the reservoir (constant S_(g)), the gaspressure drops, the gas density decreases and the GZP decreases. Thisresults in the curve 223′ where the GZP is lower than in 223. This meansthat at a fixed gas saturation, a lower gas pressure results in a biggerenvelope. Note that the wet limit 221 for the envelope is independent ofthe gas pressure. As with the effect of S_(g) on GZP, the effect ofP_(g) on GZP may also be nonlinear. More than two curves may begenerated and linear or nonlinear interpolation or extrapolation may beused for quantitative estimation of gas pressure.

An example from a natural gas reservoir is shown in FIG. 7. Near the topof the section, the curve 261 is the wet bound, the curve 263 is thecurve at the initial gas pressure for S_(g)=1. The curve 265 is theS_(g)=1 curve for a depleted reservoir gas pressure that corresponds toa pressure at which the reservoir would be abandoned. The actualmeasurements 267 lie close to the curve 263, indicating that at least inthe top of the section, the reservoir has not been pressure depleted.

The same is not true towards the bottom of the section. The curve 261′is the wet bound, the curve 263′ is the curve at the initial reservoirgas pressure for S_(g)=1. The curve 265′ is the S_(g)=1 curve for adepleted reservoir gas pressure. The actual measurements 267′ lie closeto the curve 265′, indicating that the deeper gas reservoirs have beenpressure depleted and the gas pressure reduced. This has an importantbearing on the reservoir development.

The present invention recognizes the fact that the assumptions ofconstant gas pressure or the assumption of constant gas saturation maynot be satisfied. Accordingly, in one embodiment of the invention, theCarbon/Oxygen (C/O) ratio is also determined. As would be known to thoseversed in the art, the inelastic gamma rays scattered at an energy ofabout 4.4 MeV are primarily due to carbon nuclei in the formation. Theinelastic gamma rays scattered at an energy of about 6.13 MeV areindicative of oxygen nuclei in the formation. The C/O ratio is anindependent measurement that is affected by both the gas saturation andthe gas pressure.

In order to see how this may be used, we first examine FIG. 6 in moredetail and draw some inferences from it. We note that a point such as281 in FIG. 6 (which has a given value of GZP and effective porosity)can be the result of different combinations of gas pressure and gassaturation, or, equivalently, gas density and gas saturation. Using aplurality of values of ρ_(g), this relation may be qualitativelyrepresented by the curve 283 in FIG. 8.

We next see what information about gas saturation may be obtained fromthe C/O ratio. The C/O ratio for a given borehole diameter and casingdiameter depends upon effective porosity, the fluid in the rock and thefluid in the borehole. An example is given in FIG. 9. The abscissa isthe effective porosity and the ordinate is the C/O ratio. The curves301, 303 and 305 for an oil saturated rock, a gas saturated rock and awater saturated rock, all for a borehole full of oil. The curves 307,309, 311 are corresponding curves for a borehole full of gas, while thecurves 313, 315, 317 are for a water filled borehole. The curves in FIG.9 are for the LS detector in a borehole of diameter 8.5 inches (21.59cm) and a casing diameter of 5 inches (12.7 cm). Similar curves existfor the SS detector.

Again, for a given effective porosity, a measured value of the C/O ratiocan be obtained from various combinations of S_(g) and ρ_(g) for aplurality of values of the effective porosity. This is represented inFIG. 8 by the curve 287. The intersection of curves 287 and 283 at thepoint 285 gives the unique solution for S_(g) and ρ_(g) corresponding tothe observed values of the GZP and the C/O ratio. The gas pressure isthen determinable from the gas density and the equation of state of thegas. The simplest known example of an equation of state is the onerelating the pressure P, the volume V, and the absolute temperature T ofone mole of a perfect gas; that is, PV=RT, in which R is the universalgas constant. Dense real gases have more complicated equations of statebut these are determinable for natural gas.

This embodiment of the invention is illustrated by the flow chart ofFIG. 10. Pulsed neutron measurements are made 353 at a particular depth.The GZP and the C/O ratio are determined 355, 357 from the pulsedneutron measurements. From known values of effective porosity 351, theS_(g) and ρ_(g) are determined 359 as discussed above. Using theequation of state, the gas pressure may be determined 361. This isrepeated for additional depths. As noted above, the GZP determination islithology specific and may further consider the effects of casing. Inview of the differences in the C/O ratio estimated by the SS and the XLSdetector, either one or a weighted combination of the estimates may beused.

The methods described above are quantitative methods for determinationof gas saturation and gas pressure. This is in contrast to prior artmethods based on density determination that are effective inqualitatively identifying the presence of gas but have little value inquantitative analysis.

The neutron source and the gamma ray detectors may be conveyed into thecased borehole on a wireline. Alternatively, the conveyance may be doneusing a slickline. For a slickline conveyed embodiment, the data arestored on a suitable memory device and may be processed upon recovery ofthe memory device at the surface or a remote location.

The processing of the measurements made in wireline applications may bedone by the surface processor 33, by a downhole processor, or at aremote location. The data acquisition may be controlled at least in partby the downhole electronics. Implicit in the control and processing ofthe data is the use of a computer program on a suitable machine readablemedium that enables the processors to perform the control andprocessing. The machine readable medium may include ROMs, EPROMs,EEPROMs, Flash Memories and Optical disks. The term processor isintended to include devices such as a field programmable gate array(FPGA).

While the foregoing disclosure is directed to the specific embodimentsof the invention, various modifications will be apparent to thoseskilled in the art. It is intended that all such variations within thescope and spirit of the appended claims be embraced by the foregoingdisclosure.

1. A method of evaluating an earth formation having a fluid therein, themethod comprising: (a) irradiating the earth formation with a nuclearsource thereof; (b) measuring radiation resulting from interaction ofthe irradiation with nuclei at at least one detector; and (c) estimatingat least in part from the measurements a value of a fluid saturationS_(g) and a fluid pressure P_(g); and (d) recording the estimated fluidsaturation and the estimated fluid pressure on a suitable medium.
 2. Themethod of claim 1 wherein estimating S_(g) and P_(g) further comprises:(i) determining from a first subset of the measurements a value of afluid zone parameter (GZP) indicative of S_(g) and P_(g) at at least onedepth in a borehole; (ii) determining from a second subset of themeasurements a value of a Carbon/Oxygen (C/O) ratio; and (iii)estimating the values of S_(g) and P_(g) using the determined value ofthe GZP and the C/O ratio.
 3. The method of claim 2 wherein the at leastone detector comprises at least two detectors and the GZP is related toa ratio of measurements made by a first one of the at least twodetectors and measurements made by another one of the at least twodetectors.
 4. The method of claim 2 wherein the second subset ofmeasurements comprises gamma rays with an energy of about 4.4 MeV and anenergy of about 6.13 MeV.
 5. The method of claim 2 wherein determiningthe values of the GZP further comprises using at least one of (i) aformation mineralogy, (ii) a formation porosity, (iii) a tool responsecharacteristic, (iv) a formation fluid density, (v) a borehole fluiddensity, (vi) a borehole diameter, (vii) a casing diameter, (viii) a gasdensity, and (ix) an equation of state.
 6. The method of claim 2 whereinestablishing the values of the GZP further comprises a Monte Carlosimulation.
 7. The method of claim 2 wherein estimating the values ofS_(g) and P_(g) further comprises determining a value of S_(g) and afluid density ρ_(g) that correspond to the determined value of GPZ andthe determined value of the C/O ratio.
 8. The method of claim 7 whereinestimating the values of S_(g) and P_(g) further comprises using anequation of state.
 9. The method of claim 1 wherein the boreholecomprises a cased borehole.
 10. The method of claim 1 wherein theinteraction comprises an inelastic scattering.
 11. The method of claim 1wherein the radiation comprises gamma radiation.
 12. The method of claim1 wherein the fluid further comprises a gas.
 13. An apparatus forevaluating an earth formation having a fluid therein, the apparatuscomprising: (a) a source of nuclear radiation configured to be conveyedin a borehole in the earth formation, the source configured to irradiatethe earth formation; (b) at least one detector configured to producesignals indicative of results of interaction of the irradiation withnuclei; and (c) a processor configured to: (A) estimate at least in partfrom the signals a value of a fluid saturation Sg and a fluid pressurePg; and (B) record the estimated fluid saturation and fluid pressure ona suitable medium.
 14. The apparatus of claim 13 wherein the processoris configured to estimate the value of Sg and Pg by further: (i)determining from a first subset of the signals a value of a fluid zoneparameter (GZP) indicative of a fluid saturation Sg and a fluid pressurePg at at least one depth in the borehole, (ii) determining from a secondsubset of the signals a value of a carbon/oxygen (C/O) ratio; and (iii)using the determined value of the GZP and the determined value of theC/O ratio.
 15. The apparatus of claim 14 wherein at least one detectorcomprises at least two detectors and the processor is configured todetermine the GZP using a ratio of measurements made by a first one ofthe at least two detectors and measurements made by anther one of the atleast two detectors.
 16. The apparatus of claim 14 wherein the secondsubset of measurements comprises gamma rays with an energy of about 4.4MeV and an energy of about 6.13 MeV.
 17. The apparatus of claim 14wherein the processor is further configured to establish a value of theGZP using at least one of (i) a formation mineralogy, (ii) a formationporosity, (iii) a tool response characteristic, (iv) a formation fluiddensity, (v) a borehole fluid density, (vi) a borehole diameter, (vii) acasing diameter, (viii) a gas density, and (ix) an equation of state.18. The apparatus of claim 14 wherein the processor is configured toestablish a value of the GZP at least in part by using a Monte Carlosimulation.
 19. The apparatus of claim 14 wherein the processor isconfigured to estimate the values of S_(g) and P_(g) by furtherdetermining a value of S_(g) and a fluid density ρ_(g) that correspondto the determined value of GZP and the determined value of the C/Oratio.
 20. The apparatus of claim 14 wherein the processor is configuredto estimate the values of S_(g) and P_(g) by further using an equationof state.
 21. The apparatus of claim 13 wherein the borehole comprises acased borehole.
 22. The apparatus of claim 13 wherein the interactioncomprises an inelastic scattering.
 23. The apparatus of claim 13 furthercomprising a conveyance device configured to convey the source ofradiation into the borehole, the conveyance device selected from thegroup consisting of (i) a wireline, and (ii) a slickline.
 24. Theapparatus of claim 13 wherein the at least one detector is configured tobe responsive to gamma radiation.
 25. The method of claim 13 wherein thefluid further comprises a gas.
 26. A machine readable medium for usewith an apparatus for evaluating an earth formation having a fluidtherein, the apparatus comprising: (a) a nuclear radiation sourceconfigured to irradiate the earth formation; and (b) at least onedetector configured to produce signals indicative of results ofinteraction of the irradiation with nuclei; the medium comprisinginstructions which enable a processor to: (c) determine at least in partfrom the signals a value of a fluid zone parameter (GZP) indicative of afluid saturation Sg and a fluid pressure Pg at at least one depth in theborehole, (d) determine from the signals a value of carbon/oxygen (C/O)ratio; and (e) estimate a value of Sg and a value of Pg from thedetermined value of the GZP and the determined value of the C/O ratio.27. The medium of claim 26 further comprising at least one of: (i) aROM, (ii) an EPROM, (iii) an EEPROM, (iv) a Flash Memory, and (v) anoptical disk.